20030508Application.pdf

- 8(,7
EXECUTIVE OFFICES f?ECEI VE r:~IYI
INTERMOUNTAIN GAS COMPANY LED I
:::......
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX
iu7,l.
6O97
U~f1AY-7 PM 3:58
May 7 , 200&UT.
i~~(~.!h) iUjJl IC
III i ItS COMMISSION
Ms. Jean Jewell
Commission Secretary
Idaho Public Utilities Commission
472 W. Washington St.
P. O. Box 83720
Boise , 10 83720-0074
RE:Intermountain Gas Company
Case No. INT-03~
Dear Ms. Jewell:
Enclosed for filing with this Commission is a signed original and seven copies of
Intermountain Gas Company s Application and supporting Workpapers for Authority to
Change Its Prices on July 1 , 2003.
Please acknowledge receipt of this filing by stamping and returning a photocopy of this
Application cover letter to us.
If you have any questions or require additional information regarding the attached, please
contact me at 377-6168.
Very truly yours~pY-
chael P. McGr
irector
Market Services and Regulatory Affairs
MPM/slk
Enclosures
cc:W. C. Glynn
N. C. Hedemark
M. E. Huntington
P. R. Powell
M. W. Richards, Jr.
INTERMOUNTAIN GAS COMPANY
CASE NO. INT-O3-CJl
APPLICATION,
EXHIBITS,
AND
WORKP APERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
for Authority to Change Its Prices on July 1 2003
(July 1, 2003 Purchased Gas Cost Adjustment Filing)
Morgan W. Richards, Jr.
MOFFATT, THOMAS, BARRETT, ROCK & FIELDS, CHARTERED
PO Box 829, Boise, Idaho 83701
Telephone [phone]
MTBR&F 11-500.316
Attorneys for Intermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of
INTERMOUNTAIN GAS COMPANY
for Authority to Chan e Its Prices
Case No. INT -03- ()
APPLICATION
Intermountain Gas Company ("Intermountain ), an Idaho corporation with general offices
located at 555 South Cole Road, Boise, Idaho, hereby requests authority, pursuant to Idaho Code
Sections 61-307 and 61-622, to place in effect July 1, 2003 new rate schedules which will increase
its annualized revenues by $61 million, pursuant to the Rules of Procedure of the Idaho Public
Utilities Commission ("Commission ). Because of changes in Intermountain's gas related costs, as
described more fully in this Application, Intermountain s earnings will not be increased as a result
of the proposed changes in prices and revenues. Intermountain s current rate schedules showing
proposed changes are attached hereto as Exhibit No.1 and are incorporated herein by reference.
Intermountain's proposed rate schedules are attached hereto as Exhibit No.2 and are incorporated
herein by reference.
Communications in reference to this Application should be addressed to:
Michael E. Huntington
Vice President - Marketing & External Affairs
Intermountain Gas Company, Post Office Box 7608, Boise, ID 83707
and
Morgan W. Richards, Jr.
Moffatt, Thomas, Barrett, Rock & Fields, Chartered
Post Office Box 829, Boise, ID 83701
In support ofthis Application, Intermountain does allege and state as follows:
APPLICATION - 2
Intermountain is a gas utility, subject to the jurisdiction of the Idaho Public Utilities
Commission, engaged in the sale of and distribution of natural gas within the State of Idaho under
authority of Commission Certificate No. 219 issued December 2, 1955, as amended and
supplemented by Order No. 6564, dated October 3, 1962.
Intermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County - Boise, Eagle, Garden City, Kuna, Meridian, and Star;
Bannock County - Chubbuck, Inkom, Lava Hot Springs, McCammon, and Pocatello;
Bear Lake County - Georgetown, and Montpelier;
Bingham County - Aberdeen, Basalt, Blackfoot, Firth, Fort Hall, MorelandlRiverside, and Shelly;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon, Idaho Falls, Iona, and Ucon;
Canyon County - Caldwell, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County - Bancroft, Conda, Grace, and Soda Springs;
Cassia County - Burley, Dec1o, Malta, and Raft River;
Elmore County - Glenns Ferry, Hammett, and Mountain Home;
Fremont County - Parker, and St. Anthony;
Gem County - Emmett;
Gooding County - Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - Heyburn, Paul, and Rupert;
Owyhee County - Bruneau, Homedale;
Payette County - Fruitland, New Plymouth, and Payette;
Power County - American Falls;
Twin Falls County - Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County - Weiser.
Intermountain's properties in these locations consist of transmission pipelines, a compressor
station, a liquefied natural gas storage facility, distribution mains, services, meters and regulators
and general plant and equipment.
II.
Intermountain seeks with this Application to pass through to each of its customer classes a
change in gas related costs resulting from: 1) changes in Intermountain's firm transportation and
storage costs resulting from Intermountain's management of its storage and firm capacity rights on
pipeline systems including the Williams Northwest Pipeline ("Williams" or "Northwest"), 2) an
APPLICATION - 3
increase in Intermountain s Weighted Average Cost of Gas ("W ACOG"), 3) an updated customer
allocation of gas related costs pursuant to the Company s Purchased Gas Cost Adjustment
provision, and 4) the inclusion of temporary surcharges and credits for one year relating to gas and
interstate transportation costs from Intermountain s deferred gas cost account. Exhibit No.
contains pertinent excerpts from pipeline and related facilities tariffs. Intermountain also seeks with
this Application to eliminate the temporary surcharges and credits included in its current prices
during the past 12 months, pursuant to Case No. INT-02-03. The aforementioned changes would
result in an overall price increase to Intermountain s RS-, RS-, GS-, and LV-l customers and a
decrease to Intermountain s T-1 and T-2 customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain s Purchased Gas Cost Adjustment ("PGA"), initially approved by this
Commission in Order No. 26109, Case No. INT-95-, and additionally approved through
subsequent proceedings.
Exhibit No.4 summarizes the price changes in: 1) Intermountain's base rate gas costs and its
rate class allocation, and 2) adjusting temporary surcharges or credits flowing through to
Intermountain s direct sales and transportation customers. Exhibit No.' s 3 and 4 are attached hereto
and incorporated herein by reference.
III.
The current prices of Intermountain are those approved by this Commission in Order
No. 29068, Case No. INT-02-03.
IV.
Intermountain s proposed prices incorporate all price changes impacting Intermountain
Interstate Capacity including, but not limited to, prices charged by Northwest which have
transpired since Intermountain s last PGA filing in Case No. INT-02-03. Exhibit No., Lines
through 19 details the proposed changes in Intermountain prices resulting from
Intermountain s natural gas interstate transportation and storage costs.
Intermountain s review of the adequacy of its interstate transportation and storage
services is performed on an annual basis under design weather and certain load growth
assumptions. A summary of the methodology incorporated within this annual review was
included in the Company s Integrated Resource Plan, which is currently on file with this
APPLICATION - 4
Commission. Intermountain s interstate pipeline capacity was forecast to be in a deficit position
thereby jeopardizing the Company s ability to deliver an uninterrupted supply of natural gas to its
firm sales customers during the coming winter heating seasons. Intermountain continues to take
the necessary steps to manage its interstate pipeline capacity and storage in order to insure an
uninterrupted flow of natural gas to its firm sales customers and has procured an incremental
amount of economically priced interstate transportation to ensure such. Because ofthe increase in
customer demand, no unit price increase is sought from this additional purchase of capacity.
Exhibit No., Rows 3-, include the costs for this incremental interstate transportation.
The W ACOG reflected in Intermountain's proposed prices is $0.50305 per therm, as shown
on Exhibit No., Lines 25 through 28, Column (t). This compares to $0.32000 per therm currently
included in the Company s tariffs. Natural gas is a commodity traded in the open market and, as
with all other commodities, is subject to the same laws of supply and demand. The supply of natural
gas seeks equilibrium with demand without ever actually achieving it. Natural gas prices become
volatile, within a range of volatility, as available supplies seek symmetry with demand or visa versa.
As was again played out in the marketplace over the last several months, high natural gas prices
indicative of weakening supplies have spurred on additional exploration and production and, as
natural gas supplies become more plentiful, market prices should decline. Exhibit No.
demonstrates the relationship between natural gas prices and drilling activity in North America.
Exhibit No.5 is attached hereto and incorporated herein by reference.
Intermountain believes that current futures prices, subject to the laws of supply and demand
are poised for further softening. However, liquidity in the market is sustained by contrary opinions
and natural gas prices could indeed realize the levels included in this Application, which are the
forward prices currently available through the use of financial derivatives as of May 5, 2003.
Although current commodity futures prices dictate the use of this $0.50305 per therm W ACOG
Intermountain continues to remain vigilant in monitoring natural gas prices and is committed to
come before this Commission prior to this winters heating season with an Application to further
amend these proposed prices, should these forward prices materially deviate from the $0.50305 per
thermo Timely natural gas price signals and the accounting for any cost differences brought about by
these volatile markets, facilitated through the use of the PGA mechanism, enhances our customers
APPLICATION - 5
ability to make timely and informed energy use decisions and ensures they only pay the actual cost
of such supplies. It is important to continue to alert our customers in a timely manner to these
impending increases before their higher natural gas usage is before them.
VI.
Pursuant to Case No. INT-02-, Intermountain has included temporary surcharges and
credits in its July 1 , 2002 prices for the principal reason of collecting or passing back to its
customers deferred gas cost charges and benefits, as outlined in Case No. INT-02-03. Line 33 of
Exhibit No.4 reflects the elimination of these temporary surcharges and credits.
VII.
Intermountain s PGA tariff includes provisions whereby Intermountain's proposed prices
will be adjusted for updated customer class sales volumes and purchased gas cost allocations
pursuant to the Company s approved cost of service methodology. Intermountain's proposed prices
include a fixed cost collection adjustment pursuant to these PGA provisions, as outlined on Exhibit
No., Line 24. The price impact of this adjustment is included on Exhibit No., Line No. 34.
Exhibit No.6 is attached hereto and incorporated herein by reference.
VIII.
Intermountain is party to certain agreements whereby Intermountain has released segmented
portions of its firm capacity rights when not needed to meet its customer needs. Intermountain
proposes to pass back to its customers the benefits generated from the capacity release agreements
totaling $2.4 million. Exhibit No., Line 1, reflects the inclusion of the $2.4 million credit.
Intermountain proposes to pass back this amount via the per therm credit as detailed on Exhibit
No.8. Exhibit No.'s 7 and 8 are attached hereto and incorporated herein by reference.
IX.
Intermountain proposes to allocate deferred gas costs from its Account No. 186 balance to
its customers through temporary price adjustments to be effective during the 12-month period
ending June 30, 2004, as follows:
1) Intermountain has been deferring in its Account No. 186 fixed gas costs. The
debit amount shown on Exhibit No., Line 14, Cot (b) of $1.6 million is predominantly
attributable to the collection of interstate pipeline capacity costs and the true-up of expense issues
previously ruled on by this Commission. Intermountain proposes to collect or pass back these
APPLICATION - 6
balances via the per therm surcharges and credits, as detailed on Exhibit No.9 and included on
Exhibit No., Line 2. Exhibit No.9 is attached hereto and incorporated herein by reference.
2) Intermountain has been deferring in its Account No. 186 deferred gas cost debits
of $4.4 million, as shown on Exhibit No.1 0, Line 2, Co!. (b), attributable to Intermountain's under
collection of variable gas costs since July 1 , 2002. Intermountain proposes to collect this debit
balance via a per therm surcharge, as shown on Exhibit No. 10, Line 4, Co!. (b) and included on
Exhibit No., Line 3. Exhibit No. 10 is attached hereto and incorporated herein by reference.
Intermountain has allocated the proposed price changes to each of its customer classes
based upon Intermountain s PGA provision. A straight cents per therm price decrease was not
utilized for the T -1 tariff. No fixed costs are currently recovered in the tail block of Intermountain'
l tariff. Absent Williams' firm transportation TF-l Commodity Charge, the proposed decrease
in the T -1 tariff is fixed cost related, and therefore, a cents per therm decrease was made only to the
first two blocks of the tariff for these fixed costs.
XI.
The T -1 tariff filed with this Application eliminates that portion of the tariff applicable to
therms used as feedstock in the production of ammonia. Coincident with the recent closure of the
R. Simplot Ammonia Production Plant in Pocatello, Idaho, there are no customers within the
Intermountain Gas Company service territory using natural gas as a feedstock in the production of
ammonIa.
XII.
The proposed decrease in the T -2 tariff is fixed cost related, and therefore, a cents per therm
decrease was made only to the T-2 demand charge for these fixed costs.
XIII.
Exhibit No. 11 is an analysis of the overall price changes by class of customer. Exhibit No.
11 is attached hereto and incorporated herein by reference.
XIV.
The proposed overall price change herein requested among the classes of service of
Intermountain will not affect Intermountain's earnings, and is just, fair, and equitable.
APPLICATION - 7
xv.
This Application is filed pursuant to the applicable statutes and the Rules and Regulations
of the Commission. This Application has been brought to the attention of Intermountain
customers through a Customer Notice and by a Press Release sent to daily and weekly newspapers
and major radio and television stations in Intermountain s service area. The Press Release and
Customer Notice are attached hereto and incorporated herein by reference. Copies of this
Application, its Exhibits, and Workpapers have been provided to those parties regularly intervening
in Intermountain's rate proceedings.
XVI.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission s Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
APPLICATION - 8
WHEREFORE, Intermountain respectfully petitions the Idaho Public Utilities Commission
as follows:
a. That the proposed rate schedules herewith submitted as Exhibit No.2 be approved
without suspension and made effective as of July 1 , 2003 in the manner shown on Exhibit No.
That this Application be heard and acted upon without hearing under modified
procedure, and
c. For such other relief as this Commission may determine proper herein.
DATED at Boise, Idaho, this 7th day of May, 2003.
INTERMOUNTAIN GAS COMPANY MOFFATT, THOMAS, BARRETT, ROCK
& FIELDS, CHARTERED
Michael E. Huntington
Vice President
Marketing & External Affairs
By tf.t GJ \ ~J
Morgan W. R'ichards , Jr. I'
Of the Firm
Attorneys for Intermountain Gas Company
APPLICATION - 9
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 7th day of May, 2003, I served a copy of the
foregoing Case No. !NT -03- upon:
Lisa Nordstrom
Deputy Attorney General
Idaho Public Utilities Commission
472 W. Washington St., PO Box 83720
Boise, ID 83720-0074
Edward A. Finklea
Paula E. Pyron
Energy Advocates LLP
526 NW 18th Avenue
Portland, OR 97209
R. Scott Pasley
J. R. Simplot Company
PO Box 27
Boise, ID 83707
David Hawk
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Conley E. Ward, Jr.
Givens, Pursley, Webb & Huntley
277 N. 6th St., Suite 200
PO Box 2720
Boise, ID 83701
Paula Pyron
Northwest Industrial Gas Users
4113 Wolf Berry Court
Lake Oswego, OR 97035
Wendell M. Phillips
615 South Phillippi Street
Boise, ID 83705
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
Mic el P.
Di ector
arket Services and Regulatory Affairs
APPLICATION - 9
EXHIBIT NO.
CASE NO. INT-G-O3-
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(9 pages)
Exhibit No.
Case No. INT-O3-c1/
Intermountain Gas Company
Page 1 of 9
COMPARISON OF PROPOSED JULY 1, 2003 PRICES
TO JULY 1, 2002 PRICES
July I, 2002 Proposed
Line Prices per Proposed July I, 2003
No.Rate Class INT-02-Adjustment Prices
(a)(b)(c)(d)
RS-
April - November 70862 0.23826 94688
December - March 59606 23826 83432
RS-
April- November 0.57698 23129 80827
December - March 0.54335 0.23129 77464
GS-
April- November
Block 1 60083 23886 83969
Block 2 57910 23886 81796
Block 3 55808 23886 79694
December - March
Block 1 54998 23886 78884
Block 2 52878 23886 76764
Block 3 50832 23886 74718
CNG Fuel 0.50832 0.23886 74718
LV-I (1)
Block 1 0.40965 22029 2 62994
Block 2 37116 22029 3 0.59145
Block 3 30188 22479 4 52667
Block 1 11848 (0.00450) 2 11398
Block 2 07999 (0.00450) 3 07549
Block 3 01071 00000 4 01071
Demand Block 1 1.53849 (0.00831)1.53018
Demand Block 2 73691 (0.00831)72860
Commodity Charge 00656 00000 00656
Over-Run Service 04915 00000 04915
1 The LV-l Adjustment is ca1culated by taking Line 22 - 24, Col (c), plus the change in the
W ACOG, plus removal of the temporary variable credit from INT -02-3 of $0.02473
plus the temporary variable debit on Exhibit 10, Line 4, Col (b)
2 See WorkpaperNo. 7, Line 13, Col (e)
3 See WorkpaperNo. 7, Line 20, Col (e)
4 See WorkpaperNo. 7, Line 21, Col (e)
LP.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thi -+Aird- Fourth Revised Sheet No. 01
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 2 of 9Name
of Utility Intermountain Gas Company
Rate Schedule RS-
RESIDENTIAL SERVICE
-t:JAlIG rUBY; UfIYIES eeuMIe6ee N.1'0.1" lith..,...
Jut, 1,200%4.A) 1,2001
Far 80ft. 19088
ft.41 B. left..' """;'t..,
AVAILABILITY:
Available to individually metered consumers not othelWise specifically provided for, using
natural gas for residential purposes.
RATE:
. Monthly minimum charge is the customer charge.
For billina periods endina ADrii throuah November
Customer Charge. $2.50 per bill. $0.94688
Commodity Charge. $0.70862 per therm
For billina periods endina December throuah March
Customer Charge. $6.50 per bill
$0.83432
Commodity Charge - $0.59606 per therm
Includes:
Temporary purchased gas cost adjustment of $(0.03915)$0.01590
Weighted average cost of gas of $0.32000 $0.50305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in theCompanys Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of theCompanys Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External AffairsEffective: July 1. 2003
LP.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirtv-+hiFd Fourth Revised Sheet No. 02 . (Page 1 of 1)
Exhibit No.
Case No. INT -O3-
Intermountain Gas Company
Page 3 of 9
Name
of Utility Intermountain Gas Company
- IBAlle PYBI::/G 1:11U:lilES SeMMlS8Ie N"""'.v...,1 EIr........4111). 1. EeeE 4..1) 1,1101
Per 8.N. 29868Rate Schedule RS-1e"18.""w611"-...b.,~MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas for several residential purposesincluding both water heating and space heating.
. RATE:
Monthly minimum charge is the customer charge.
For billina Deriods endina ADrii throuah November
Customer Charge - $2.50 per bill
$0.80827
Commodity Charge - $0.67698 per therm
For billina Deriods endina December throuah March
Customer Charge - $6.50 per bill
$0.77464
Commodity Charge $0.64335 per therm
Includes:
Temporary purchased gas cost adjustment of $(0.03839) $0.01217
Weighted average cost of gas of $0.32000 $0.50305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in theCompanys Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External AffairsEffective: July 1. 2002 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty~ Sixth Revised Sheet No. 03 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 4 of 9
Rate Schedule GS-
GENERAL SERVICE
!BAIle FUSLie Uftbt1E6 88"..981e N. Apl'l~..d ar",..II..
JIIkj 1, 2982 Jlllfi 1, loft
Per eoN. 29861
Jean B. JI.II 86eRt..)
AVAilABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed
000 therms per day, at any point on Company s distribution system. Requirements in excess of000 therms per day may be served under this rate schedule upon execution of a one-year writtenservice contract.
RATE:
Monthly minimum charge is the customer charge.
For billina Deriods endina ADril throuah November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill $0.60083*$0.83969*
Next 1,800 therms per bill $0.57910*$0.81796*
Over 2 000 therms per bill $0.55808*$0.79694*
For billina periods endina December throuah March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill $0.54998*$0.78884*
Next 1,800 therms per bill $0.52878*$0.76764*Over 2,000 therms per bill $0.50832*$0.74718*
Includes:
Temporary purchased gas cost adjustment of $(0.03877). $0.01700
Weighted average cost of gas of $0.32000 $0.50305
IsSued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External AffairsEffective: July 1 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thi -f.iftA Sixth Revised Sheet No. 03 Page 2 of 2
Name
of Utility Intermountain Gas Company
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 5 of 9
Rate Schedule GS-
GENERAL SERVICE (Continued)
. '
/DAIto F'UBue U1U:I'ftee e8I1MfS11o
""'10.611 . art-..
"..
4\d) 1, 18ti "wi) 1,2001PerGM.198&8lelll 8."'l1li81 SOeN"""
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel invehicular internal combustion engines.
Customer Charge - $9.50 per bill. $0.74718
. Commodity Charge - $0.50832 per therm
Includes:
Temporary purchased gas cost adjustment of $(0.03877)$0.01700
Weighted average cost of gas of $0.32000 $0.50305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in theCompanys Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time the
customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service willhave refunded to them, upon exiting the GS-1 service, any excess gas commodity ortransportation payments made by the customer during the time they were a GS-customer.
2. AIl natural gas service hereunder is subject to the General Service Provisions of theCompanys Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External AffairsEffective: July 1 , 2002- 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Fo -+AiFG Fourth Revised Sheet No. 04
Name
of Utili Intermountain Gas Com an
. Exhibit No.
Case No. INT -03-
Intermountain Gas Company
Page 6 of 9
IDIId Ie P'UBue unum;a "9111.619
; .
t\fIpl'O'.ed Elfeel.i"~1,1I1I2 ""6 100%
rere.H.29IH
JeeRB."....k~nbhtRate Schedule LV..1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any. existing customer receiving service under the Company s rate schedules LV-, T-1, or T-, or any newcustomer whose usage does not exceed 500,000 therms annually, upon execution of a one;.yearminimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill $0.10965*$0.62994*Next 500,000 therms per bill $0.37116*$0.59145*AmoUnt Over 750,000 therms per bill $0.30188**$0.52667**
The above prices include weighted average cost of gas of $0.32000 $0.50305
Includes temporary purchased gas cost adjustment of $(0.02944)$0.01475
**
Includes temporary purchased gas cost adjustment of $(0.02173)$0.01701
PURCHASED GAS COST ADJUSTMENT (PGA):
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of theCompanys Tariff, of which this Rate Schedule is a part.
2. Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, theexpiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service,all gas and/or interstate transportation related costs to serve the customer during the LV-1 contractperiod not borne by the customer during the LV-1 contract period. Any LV-1 customer will haverefunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
. payments made by the customer during the LV-1 contract period. 3. In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period used less
than the contract minimum of 200,000 therms, an additional amount shall be billed. The additionalamount shall be calculated by billing the deficit usage below 200~000 therms at the T -1 Block 1 rate. Thecustomers future eligibility for the LV-1 Rate Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External AffairsEffective: July 1 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirtieth Revised Sheet No. 05 (Pa e 1 of 2)
Name
of Utili Intermountain Gas Com an
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 7 of 9
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
IBAil8 FI:IBUe IfflU'I1E8 88MMI991OH"",Fe':." EWeeH.
J1df 1. ava "II~ 1,1802
Per 0"'. a868
oP-Je.R 9. Je'aIISeare.....
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company distribution system to any existingcustomer receiving service under the Company's rate schedules LV-, T-, or T-2, upon execution of a one yearminimum written service contract for firm transportation service in excess of 200 000 therms per year.
MONTHLY RATE:
Commodity Charge:
All usage ather than as feedstock in the praduotion af ammonia:
Block One: First 250 000 therms transported $0.11818*$0.11398*Block Two: Next 500,000 therms transported $0.07999*$0.07549*Block Three: Amount over 750,000 therms transported ~ $0.01071
All therms used as feedstock in the production af ammonia: ~ $0.02525
Includes temporary purchased gas cost adjustment of $(-0.00471)$(0.00226)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
s PurchasedGas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, ofwhichthis Rate Schedule is a part.
2. The customer shall negotiate a Maximum Daily Firm Quantity (MDFQ) amount, which will be stated in and will bein effect throughout the term of the service contract. The MDFQ shall not exceed the customer's historicalmaximum daily usage, as agreed to by the Company.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the availability of firminterstate transportation to service Intermountain s system, all such usage may be transported and billed undereither secondary rate schedule T-3 or T -4. The secondary rate schedule to be used shall be predetermined bynegotiation between the Customer and Company, and shall be included in the service contract. All volumestransported under the secondary rate schedule are subject to the provisions of the applicable rate schedule T -3 orT-4.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Twen ..FiftA Sixth Revised Sheet No. 05
Name
of Utili Intermountain Gas Com an
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 8 of 9
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
(Continued)
3. In the event that total deliveries to any customer within the last three contract periods met or exceeded the
200,000 therm threshold, but the customer during the current contract period used less than the contract
minimum of 200,000 therms, an additional amount shall be billed. The additional amount shall be calculated
by billing the deficit usage below 200 000 therms at the T-1 Block 1 rate. The customer's future eligibility forthe T-1 Rate Schedule will be renegotiated with the Company.
lDAIle Pileus I:ITllITIg;; eeMMI3SION
APPREM:B ~fi"eC1'1YE:
JILJ g '98 . ':Jl31'SaRA, 0 '\1 .77&S4-
~--
JZ. _LI H
41!Clu:11IK1
In the event that total deliveries to any new customer did not meet the 200 000 therm threshold during thecurrent contract period, an additional amount shall be billed. The additional amount shall be calculated bybilling the customer's total usage during that contract period at the Rate Schedule GS-1 ~Iock 3 rate,adjusted for the cost of gas, and then subtracting the amounts previously billed during the annual contract
period. The customer's future eligibility for the T-1 Rate Schedule will be renegotiated with the Company.
4. Usage above 750 000 therms in any given month which is in excess of the customer's historical maximum
above 750,000 therms for that same month, such historic usage measured by the 3 years ended September
30, 1995, will be billed at the currently effective Block 2 price.
a. The Gustomor using transported gas as feedstock for ammonia production shall be metored separatoly for
such \;lEDge.
65. Embedded in this service is the cost of firm interstate pipeline reservation charges and distribution costs.
76. The customer is responsible for procuring its own supply of natural gas under this Rate Schedule. Thecustomer understands and agrees that the Company is not responsible to deliver gas supplies to thecustomer which have not been nominated and scheduled for delivery by the interstate pipeline.
87. Any T-1 customer who exits the T-1 service at any time (including, but not limited to, the expiration of thecontract term) and does not sign an LV-1 or T-2 service contract will pay to Intermountain Gas Company,upon exiting the T-1 service, all pipeline reservation and distribution capacity costs incurred to serve the
customer during the T-1 contract period not borne by the customer during the T-1 contract period. Any T-customer who exits the T-1 service and does not sign an LV-1 or T-2 service contract will have refunded tothem, upon exiting the T-1 service, any excess pipeline reservation and distribution capacity costs payments
made by the customer during the T-1 contract period.
Issued by: Intermountain Gas Company
By: RuDDcll L. Worthan Michael E. Huntington Tiitle: viae r'recidentand Recource r'lanning Vice President -Marketing and External AffairsEffective: Julv 1. 2003
Governmental Affaire
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
+eRtR Eleventh Revised Sheet No. 10 (Page 1 of 2)
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 9 of 9
Name
of Utility Intermountain Gas Company IDAlle PlIBue ~U'RE:8 eBMMISSION
""1'1'0":811 .
. .
Dft.,Uw"
Jllly 1, 2982 . 4111) 1,Iaat
r". B.N-II0aS
JeliR D. JaneK SeeNeel')'
Rate Schedule T-
FIRM TRANSPORTATION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to anyexisting T -2 customer whose daily contract demand for nonammonia therms on any given day meets orexceeds a predetermined level agreed to by the customer and the Company upon execution of a one-yearminimum written service contract for firm transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
First 15,000 therms
Amount over 15,000 therms
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Rate Per Therm
$1.63849*$1.53018*
$0.73691*$0.72860*
$0.00656
Commodity Charge:
For Therms Transported In Excess Of MDFQ:$0.04915
Includes temporary purchased gas cost adjustment of $(0.09627) $(0.09117)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the CompanyPurchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the CompanyTariff, of which this Rate Schedule is a part.
The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and willbe in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firmdemand relief will be afforded to those T -2 customers paying both demand and commodity chargesfor gas when, in the Company s judgment, such relief is warranted.
The actual therm usage for the month or the MDFQ times the number of days in the billing monthwhichever is less, will be billed at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas Company
By: Michael E. Huntington
Effective: July 1 , 2002 2003 Title: Vice President - Marketing and External Affairs
EXHIBIT NO.
CASE NO. INT -O3-
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(8 pages)
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty- Fourth Revised Sheet No. 01 (Page 1 of 1)
Name
of Utility
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of 8
Intermountain Gas Company
Rate Schedule RS-
RESIDENTIAL SERVICE
AVAilABILITY:
Available to individually metered consumers not otherwise specifically provided for, using
natural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endina April throuah November
Customer Charge - $2.50 per bill
Commodity Charge - $0.94688 per therm
For billina periods endina December throuah March
Customer Charge - $6.50 per bill
Commodity Charge - $0.83432 per therm
Includes:
Temporary purchased gas cost adjustment of $0.01590
Weighted average cost of gas of $0.50305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 , 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty- Fourth Revised Sheet No. 02
Name
of Utility
(Page 1 of 1)
Intermountain Gas Company
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 2 of 8
Rate Schedule RS-
MULTIPLE USE RESIDENTIAL SERVICE
AVAilABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endina April throuah November
Customer Charge - $2.50 per bill
Commodity Charge - $0.80827 per therm
For billina periods endina December throuah March
Customer Charge - $6.50 per bill
Commodity Charge $0.77464 per therm
Includes:
Temporary purchased gas cost adjustment of $0.01217
Weighted average cost of gas of $0.50305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Sixth Revised Sheet No. 03 (Page 1 of 2)
Name
of Utility
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 3 of 8
Intermountain Gas Company
Rate Schedule GS-
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed
000 therms per day, at any point on Company s distribution system. Requirements in excess of
000 therms per day may be served under this rate schedule upon execution of a one-year written
service contract.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endina April throuah November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill CID $0.83969*
Next 1 800 therms per bill CID $0.81796*
Over 2,000 therms per bill CID $0.79694*
For billina periods endina December throuah March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill CID $0.78884*
Next 1 ,800 therms per bill CID $0.76764*
Over 2,000 therms per bill CID $0.74718*
Includes:
Temporary purchased gas cost adjustment of $0.01700
Weighted average cost of gas of $0.50305
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Sixth Revised Sheet No. 03 (Page 2 of 2)
Name
of Utility
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 4 of 8
Intermountain Gas Company
Rate Schedule GS-
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in
vehicular internal combustion engines.
Customer Charge - $9.50 per bill
Commodity Charge - $0.74718 per therm
Includes:
Temporary purchased gas cost adjustment of $0.01700
Weighted average cost of gas of $0.50305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time the
customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service will
have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
transportation payments made by the customer during the time they were a GS-
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1, 2003
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Forty Fourth Revised Sheet No. 04 (Page 1 of 2)
Name
ofUliIi
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 5 of 8
Intermountain Gas Com an
Rate Schedule LV-
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing customer receiving service under the Company s rate schedules LV-, T-1, or T-2, or any new
customer whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill ~ $0.62994*
Next 500 000 therms per bill ~ $0.59145*
Amount Over 750 000 therms per bill ~ $0.52667**
The above prices include weighted average cost of gas of $0.50305
Includes temporary purchased gas cost adjustment of $0.01475
**
Includes temporary purchased gas cost adjustment of $0.01701
PURCHASED GAS COST ADJUSTMENT (PGA):
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this Rate Schedule is a part.2. Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, the
expiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service,
all gas and/or interstate transportation related costs to serve the customer during the LV-1 contract
period not borne by the customer during the LV-1 contract period. Any LV-1 customer will have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
payments made by the customer during the LV-1 contract period.3. In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period used less
than the contract minimum of 200,000 therms, an additional amount shall be billed. The additional
amount shall be calculated by billing the deficit usage below 200,000 therms at the T -1 Block 1 rate. The
customer s future eligibility for the LV-1 Rate Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2003
Vice President - Marketing and External Affairs
Name
of UtilitY
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 6 of 8
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirtieth Revised Sheet No. 05 (Page 1 of
Intermountain Gas Company
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any existing
customer receiving service under the Company s rate schedules LV-, T-, or T-, upon execution of a one year
minimum written service contract for firm transportation service in excess of 200 000 therms per year.
MONTHLY RATE:
Commodity Charge:
Block One: First 250,000 therms transported (g) $0.11398*Block Two: Next 500,000 therms transported (g) $0.07549*
Block Three: Amount over 750,000 therms transported (g) $0.01071
Includes temporary purchased gas cost adjustment of $(0.00226)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Companys Purchased
Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company s Tariff, of which
this Rate Schedule is a part.
2. The customer shall negotiate a Maximum Daily Firm Quantity (MDFQ) amount, which will be stated in and will be
in effect throughout the term of the service contract. The MDFQ shall not exceed the customer s historical
maximum daily usage, as agreed to by the Company.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the availability of firm
interstate transportation to service Intermountain s system, all such usage may be transported and billed under
either secondary rate schedule T-3 or T-4. The secondary rate schedule to be used shall be predetermined by
negotiation between the Customer and Company, and shall be included in the service contract. All volumes
transported under the secondary rate schedule are subject to the provisions of the applicable rate schedule T-3 or
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 , 2003
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Twenty Sixth Revised Sheet No. 05 (Page 2 of
Name
of Utilitv
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 7 of 8
Intermountain Gas Company
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
(Continued)
3. In the event that total deliveries to any customer within the last three contract periods met or exceeded the
200 000 therm threshold, but the customer during the current contract period used less than the contract
minimum of 200 000 therms, an additional amount shall be billed. The additional amount shall be calculated
by billing the deficit usage below 200 000 therms at the T-1 Block 1 rate. The customer s future eligibility for
the T -1 Rate Schedule will be renegotiated with the Company.
In the event that total deliveries to any new customer did not meet the 200 000 therm threshold during the
current contract period, an additional amount shall be billed. The additional amount shall be calculated by
billing the customer s total usage during that contract period at the Rate Schedule GS~1 Block 3 rate
adjusted for the cost of gas, and then subtracting the amounts previously billed during the annual contract
period. The customer s future eligibility for the T-1 Rate Schedule will be renegotiated with the Company.
4. Usage above 750,000 therms in any given month which is in excess of the customer s historical maximum
above 750 000 therms for that same month, such historic usage measured by the 3 years ended September
30, 1995, will be billed at the currently effective Block 2 price.
5. Embedded in this service is the cost of firm interstate pipeline reservation charges and distribution costs.
6. The customer is responsible for procuring its own supply of natural gas under this Rate Schedule. The
customer understands and agrees that the Company is not responsible to deliver gas supplies to the
customer which have not been nominated and scheduled for delivery by the interstate pipeline.
7. Any T-1 customer who exits the T-1 service at any time (including, but not limited to, the expiration of the
contract term) and does not sign an LV-1 or T-2 service contract will pay to Intermountain Gas Company,upon exiting the T-1 service, all pipeline reservation and distribution capacity costs incurred to serve the
customer during the T-1 contract period not borne by the customer during the T-1 contract period. Any T-
customer who exits the T-1 service and does not sign an LV-1 or T-2 service contract will have refunded to
them, upon exiting the T-1 service, any excess pipeline reservation and distribution capacity costs payments
made by the customer during the T-1 contract period.
Issued by: Intermountain Gas Company
By: Michael E. Huntington
Effective: July 1 2003
Tiitle: Vice President -Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Eleventh Revised Sheet No. 10 (Page 1 of 2)
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 8 of 8
Name
of Utility Intermountain Gas Company
Rate Schedule T-
FIRM TRANSPORTATION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAilABiliTY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing T -2 customer whose daily contract demand for nonammonia therms on any given day meets or
exceeds a predetermined level agreed to by the customer and the Company upon execution of a one-year
minimum written service contract for firm transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
First 15,000 therms
Amount over 15,000 therms
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Rate Per Therm
$1.53018*
$0.72860*
$0.00656
Commodity Charge:
For Therms Transported In Excess Of MDFQ:$0.04915
Includes temporary purchased gas cost adjustment of) $(0.09117)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company
Tariff, of which this Rate Schedule is a part.
The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and will
be in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief will be afforded to those T -2 customers paying both demand and commodity charges
for gas when, in the Company s judgment, such relief is warranted.
The actual therm usage for the month or the MDFQ times the number of days in the billing month,
whichever is less, will be billed at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas Company
By: Michael E. Huntington
Effective: July 1, 2003
Title: Vice President - Marketing and External Affairs
EXHIBIT NO.
CASE NO. INT -O3-
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS FROM INTERSTATE PIPELINES AND RELATED
FACILITIES
(23 pages)
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of 23
'JlI.'1".""I.,lamS
GAS p,IPELINE
295 Chipeta Way (84108)
O. Box 58900
Salt Lake City, UT 84158-0900
Phone: (801) 5~6873FAX: [phone]
January 16, 2003
TO: ALL HOLDERS OF NORTHWEST PIPELINE CORPORATION'
FERC GAS TARIFF, THIRD REVISED VOLUME NO.
Please insert the enclosed tariff sheets into your copy of Northwest's FERC Gas Tariff
Third Revised Volume No.1. A brief description of the proceedings in which these tariff
sheets were accepted or are pending is provided below. Also, enclosed isa list of
Northwest's currently effective tariff sheets as of January 16, 2003.1 "
Docket No. RP03-18-000
On October 10, 2002, Northwest filed the following tariff sheets to restor~. required
language to Northwest's tariff now that the Commission s experimental waiver of the
rate ceiling on short-term capacity release transactions has expired. Pursuant to an
order dated November 8, 2002, the Commission accepted these tariff sheets, effective
October 1, 2002.
. \
First Revised Sheet No. 5-
Twelfth Revised Sheet No.
Twelfth Revised Sheet No. 8.
Fifth Revised Sheet No. 266
Fifth Revised Sheet No. 267
Docket No. RP03-85-000
On November 20, 2002, Northwest filed the following tariff sheet to revise its tariff by
removing from the right of first refusal provisions the five-year term matching cap,
consistent with the Order on Remand issued by the Commission on October 31, 2002
in Docket No. RM98-10-011. Pursuant to an order dated December 20, 2002, the
Commission accepted this tariff .sheet, effective December 21 , 2002.
Third Revised Sheet No. 278-
1 As discussed in previous letters to All-Holders, certain tariff sheets pending in Docket Nos.
GTO2-11, RPO2-116 and RPOO-506 are included in this list.
Exhibit No.
Case No. INT-03-
Intermountain Gas Company
Page 2 of 23
All-Holders
January 16, 2003
Page 2 of 3
Docket No. RP03-86-000
.:""
On November 20,2002, Northwest filed the following tariff sheets tqrevise its tariff to
incorporate the GRI surcharges approved by the Commission for 2003. Pursuant to an
order dated December 30, 2002, the Commission accepted these tariff sheets, effectiveJanuary 1, 2003.
Twenty-Third Revised Sheet No.
TenthRevised Sheet No.
Docket No. RP03-89-000
On November 20, 2002, Northwest filed the following tariff sheet to revise the tariff to .
expressly state that Northwest permits nominations of forwardhauls up to contract
demand and backhauls up to contract demand to the same point at the same time for.
segmented capacity, pursuant to the Order on Remand issued by the Commission on .
October 31, 2002 in Docket No. RM98-10-011. Pursuant to an order dated December'
19, 2002, the Commission accepted this tariff sheet, effective December 21 , 2002.
Second Revised Sheet No. 25
Other Information
If you have questions concerning Northwest's regulatory issues, please call me or any
of the other individuals listed below:
John Woolf
Gary Kotter
Jan Caldwell
Barbara Odland
Sr. Regulatory Analyst
Manager, Certificates and Tariffs
Manager, Cost of Service and Rate Design
Office Administrator
[phone]
[phone]
[phone]
[phone]
. ,
Northwest publishes FERCWatch to provide customers with information on Northwest'
current and pending filings. It can be viewed on Northwest's EBB and Internet web site.
You may also view Northwest's tariff on its Internet web site at www.1Iine.williams.com.
Sincerely,
John A. Woolf
Enclosures
\NW AlIHolderslallholdO11603vo11.doc
Northwest PipeUne Corporation
FERC Gas Tarifl'
Third Revised Volume No.
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 3 of 23
Twenty.Tblrd Revised Sheet No.
Superseding
Twentv.Second Revised Sheet No.
STATEMENT OF RATES
Effective Rates Applicable to Rate Schedules TF-1, TF-2 and TI-
Rate Schedule and
Type of Rate
~te Schedule TF-1 (4) (5)
Reservation
(Large Customer)
High Load Factor
Low Load Factor
Volumetric
(Large Customer)
(Small Customer) (6)
Scheduled Overrun
~te Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annual Overrun
Rate Schedule TI-1
Volumetric (7)
Scheduled Overrun
(Dollars per Dth)
Base
Tariff Rate
Minimum Maximum GRI ( 1 )
00000
00000
01225
01225
01225
00000
01225
01225
01225
01225
01225
27760
27760
03000
58521
30760
27760
03000
30760
30760
30760
30760
....
00164
00102
00400
00600
00400
00400
00400
, ., .
Currently
Effective
Tariff Rate(3)
ACA(2) Minimum Maximum
00210
. 00210
00210
00210
00210
00000
00000
01435
01435
01435
00000
01225
01225
01225
01435
01435
27924
27862
03610
59331
31370
27760
03000
30760
307
31370
31370
Issued by: !.aren M.Gertsch, Director
Issued on: November 20, 2002 Effective: January I, 2003
Northwest PipeliDe Corporation
FERC Gas Tariff
Third Revised Volume No.
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 4 of 23
Twelfth ~evised Sheet No. 7
Supersediag
Eleventh Revised Sheet No.
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Scliedules SGS-2F and SGS-2I;.
(Dollars per Dth)
Rate Schedule and
Type of Rate
Currently EffectiveTariff Rate (1)
Minimum Maximum
Rate Schedule SGS-2F (2)
Demand Chaz:ge
Capacity Demand Charge
00000 01689
00000 0 . 00062
0 . 00000 01689
0 . 00000 0 . 00062
Volumetric Bid Rates
Wi thdrawal Charge
Storage Charge
Rate Schedule SGS-
Volumetric 00000 00134
!Footnotes
(1)Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.14.
(2)Rates are daily rates .computed on the basis of 365 days per year, except
that rates for leap years are computed on the basis of 366 days.
Rates are also applicable to capacity release service. (Section 22 the General Terms and Condi tions describes how bids for capaci ty release
will be evaluated.The Withdrawal Charge and Storage Charge are
applicable to Replacement Shippers bidding for capacity released on a
one-part volumetric bid basis.
Issued by: Laren M.Gertsch, Director
Issued on: October 10,1002 Effective: October 1,2002
Northwest Pipeline Corporation
FERC Gas Tariff
Third Revised Volume No.
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 5 of 23
Fourteenth l~evised Sheet No.
Superseding
Thirteenth Revised Sheet No.
STATEMENT OF RATES (Continued)
Effective Rates Applicable ~o Rate Schedule LS-
(Dollars per Dth)
" ., .
Type of Rate
Currently EffectiveTariff Rate (1)
Demand Charge ( 2 )
Capacity Charge (2)02600
, 0 . 00332
Liquefaction
Vaporization 55685
03030
~ootnotes
(1)Shippers receiving service under this rate schedule are required to
furnish fuel reimbursement in-kind at the rate specified on Sheet No.14.
(2)Rates are daily rates computed on the basis of 365 days per year, except. that rates for leap years are computed on the basis of 366 days.
Issued by: Larry Lanen, Vice President
Issued on: December 1,2000 Effective: January 1,2001
Northwest Pipeline Corporation.
FERC Gas Tariff
Third Revised Volume No.
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 6 of 23
Twelfth Revised Sheet No. 8.
. SupersedingEleventh Revised Sheet No. 8.
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS~2F and LS~2I
:\-
(Dollars per Dth)
Rate Schedule and
Type of Rate
Currently ~ffective
Tariff Rate (1)Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2)
Capacity Demand Charge (2)00000 02600
0 . 00000 00332
00000 02600
00000 00332
55685 q. 55685
03030 03030
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)Storage Capacity Charge (2)
Liquefaction
Vaporization
Rate Schedule LS-
Volumetric 00161 ;0.00826
/Footnotes
(1)Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.14.
(2)Rates are daily rates computed on th~ basis of 365 days per year, except
that rates for leap yearS-are computed on the basis of 366 days.
(3)Rates are also applicable to capacity release service. (Section 22 ofthe General Terms and Conditions describes how bids for capacity release
will be evaluated.The Vaporization Demand-Related Charge and Storage
Capacity Charge are applicable to Replacement Shippers bidding for
capacity released on a one-part volumetric bid basis.
Issued by: Laren M.Gertsdl, Director
Issued on: October 10,2002
Effective: October 1,2002
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 7 of
Wi//iiff6s
NORTHWEST PIPELINE
295 Chipeta Way (84108). P.Box58900 .
Salt Lake City. UT" 84158-0900
. Phone: [phone]
- FAX: (~01) 564-7764
April 9, 2003
TO: ALL HOLDERS OF NORTHWEST PIPELINE CORPORATION'
FERC GAS TARIFF, THIRD REVISED VOLUME N9. 1
Please insert the enclosed tariff sheet into your copy of Northwest's FERC Gas Tariff,
Third Revised Volume No.
On February 28, 2003, in Docket No. RP03-272, Northwest filed Nineteenth Revised
Sheet No. 14 to implement new fuel reimbursement factors for Northwest'
transportation and storage rate schedules. Pursuant to an order dated March 28, 2003,
the Commission accepted this sheet, to be effective April 1 , 2003.
Sincerely,
John A. Woolf
Sr. Regulatory Analyst
john.woolf~williams.com
Enclosure
allholdO40903voI1.doc
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 8 of 23
Northwest Pipeline Corporation
FERC Gas Tariff
Third Revised Volume No.Nineteenth Revised Sheet No. 14
Superseding
Ei hteenth Revised Sheet No. 14
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
ate Schedules Contained in this Tariff, Third Revised Volume No.
The rates set forth on Sheet Nos. 5, 6, 7, 8 and 8.1 are exclusiveof fuel use requirements. Shipper shall reimburse Transporter in-kindfor its fuel use requirements in accordance with Section 14 of the
eneral Terms and Conditions contained herein.
The fuel use reimbursement furnished by Sh~pers shall be asfollows for the applicable Rate Schedules included in this Tariff:
Rate
Rate
Rate
Rate
Rate
Rate
Rate
Rate
Rate
Schedule
Schedule
Schedule
Schedule
Schedule
Schedule
Schedule
Schedule
Schedule
TF-l
TF-2TI-l
SGS-
SGS-
LS-
LS-
LS-
DEX-l
11%
11%
11%
00%
00%
1. 42%
1. 42%"
42%
11%
..
The fuel use factors set forth above shall be calculated apd
djusted as explained in Section 14 of the General Terms and Conditions.
uel reimbursement quantities to be supplied by Shippers to Transporter
shall be determdned by applying the factors set forth above to' theanti ty of gas nominated for receipt by Transporter from Shipper for
transportation, for injection into storage, or for deferred exchange. aspplicable.
Issued by: Laren M.Gertsch, Director
Issued on: February 18, 2003 ElTective: Aprill. 2003
THIS PAGE INTENTIONALLY LEFT BLANK
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 9 of 23
NOVA Gas Transmission Ltd.
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 10 of 23
Page 1
Table of Rates, Tolls and Charges
TABLE OF RATES, TOLLS AND CHARGES
Service Rates, ToUs and Charges
Rate Schedule FT -Refer to Attachment "I" for the applicable FT -R Demand Rate per month and
Surcharge for each Receipt Point
Average Firm Service Receipt Price (AFSRP)$1 80.1 9/l 0
Rate Schedule FT-Refer to Attachment "I" for the applicable FT -RN Demand Rate per month and
Surchare:e for each Receipt Point
Rate Schedule FT-FT -D Demand Rate per month $175.62/1O3
Rate Schedule STFT STFT Bid Price
Minimum bid of 135% ofFT-D Demand Rate
Rate Schedule FT-Refer to Attachment "2" for the applicable FT-P Demand Rate per month and
Surcharge with the exception ofthe following service which is subject to section
2 of Rate Schedule FT-
FT-P Demand
From Receipt Point To Delivery Point Rate ($/103
1796 Bonnie Glen 3115 Usona Sales 117.
2036 Jumping Pound West 2352 Jumping Pound Int 67.
1019 Nevis South 3331 Delburne Sales 67.57
1949 RimbevlWest Summary 3405 Rimbey West Sales 117.
Rate Schedule LRS Contract Term Effective LRS Rate ($/l0 /day)
5 years
10 years
15 years
20 vears
Rate Schedule LRS-LRS-2 Rate per month $50,000
Rate Schedule LRS-LRS-3 Demand Rate per mol1th $184.76/1O3
Rate Schedule IT-Refer to Attachment "I" for the applicable IT-R Rate and Surcharge for each
Receiot Point
10. Rate Schedule IT-IT-D Rate $6.35/103
II. Rate Schedule FCS The FCS Charge is determined in accordance with Attachment "I" to the
aoolicable Schedule of Service
12. Rate Schedule OS Schedule No.Chare:e
1997-00712-83,333.month
2001-99930-899.ml;mth
2002-96214-681.00 month
2002-93602-594.month
2002-96214-42.month
13. Rate Schedule CO2 Tier CO2 Rate ($/1
532.41
425.
283.
TARIFF Effective Date: January 1, 2003, as per EUB Decision 2002-119
Exhibit No.
Case No. INT-Q3-
Intermountain Gas Company
Page 11 of 23
Amended Mar. 3, 2003
Summary of 2003 Interim Station Prices:
($/10 /month, except IT which is $/10
Firm Service Delivery:175.
Average Receipt Price:180.
Receipt Price Floor:93.
Receipt Price Ceiling:266.
interruptible Delivery:
Premium/Discount:105%100%95%110%115%
FT-FT-
FT-FT-PRICE PRICE
PRICE 1 PRICE greater Year Non-Station to -==3 to -==5 than 5- Renewable IT-Number Station Name Year Term Year Term Year Term Firm PRICE
Project
, "
Area -
~::
8000 BATTLE LAKE DVY 118.112.107.124.A448 SOCK LAKE 263.251.41 238.276.9.49A449MURRAY LAKE NORTH 185.176.167.194.A44B TOPLAND 248.01 236.224.259.1942 FIGURE LAKE SUMMARY 229.218.207.240.1944 ZAMA LAKE SUMMARY 279.266.253.293.10.1947 BRAZEAU/EAST SUMMARY 129.123.117.135.1949 RIMBEY/wESTEROSE SUMMARY 118.112.107.124.1958 EMPRESS BORDER 98.93.89.103.1963 COUSINS B&C SALES 125.119.113.131.2000 ALBERTA-C. BDR (CHART ACCOL 98.93.89.103.3804 PEMBINA INTERCONNECTION 107.102.97.112.3857 INLAND INTERCONNECTION 157.150.142.165.3858 ATMORE INTERCONNECTION 236.224.213.247.3860 JANUARY CREEK INTERCONNECTI 142.136.129.149.3861 DEMMITT #2 INTERCONNECTION 244.233.221.256.473862 SEVERN CREEK INTERCONNECTIC 98.93.89.103.3863 MONARCH INTERCONNECTION 98.93.89.103.3864 JOFFRE #2 AND #3 SALES INTERC(120.115.109.126.3866 CARBON INTERCONNECTION 98.93.89.103.3871 WESTLOCK INTERCONNECTION 279.266.253.293.10.3877 RAT CREEK INTERCONNECTION 132.126.120.138.3878 NIPISIINTERCONNECTION 279.266.63 253.293.10.3879 PRIDDIS INTERCONNECTION 98.93.89.103.3880 AECO INTERCONNECTION 98.93.89.103.3886 GORDON DALE BORDER 231.220.209.242.3887 BITTERN LAKE INTERCONNECTIOr-.279.266.253.293.10.3888 DEEP VALLEY CREEK EAST INTER(214.204.194.224.3889 MITSUE INTERCONNECTION 279.266.253.293.10.3890 VIKING INTERCONNECTION 148.141.134.156.3893 CARROT CREEK INTERCONNECTIC 125.119.113.131.3894 GILT EDGE WEST INTERCONNECTI 279.266.253.293.10.3897 CROSSFIELD EAST #2 INTERCONN 98.93.89.103.3904 CONKLIN WEST INTERCHANGE INl 279.266.253.293.10.3909 CRANBERRY SUMMARY 279.266.253.293.10.3911 RANFURL Y INTERCONNECTION 240.229.217.252.8;663912 RUNNING LAKE INTERCONNECTIOI 279.266.253.293.10.3915 HAMILTON LAKE SUMMARY 230.219.208.48 241.403916 VETERAN SUMMARY 230.42 219.208.48 241.403917 WHITEMUD RIVER/WHITEMUD WE~279.266.253.293.10.6404 MCNEILL BORDER 98.93.89.103.3868 ALBERTA-MONTANA BORDER INTE 108.103.98.114.
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 12 of 23
tt~
TransCanada
1ft bus(m!SS ~ dl!lfver
Border Heat Values, Empress, McNeill & AlBC
Empress Border McNeill Border
Forecast Actual HV Forecast Actual HVDate
(MJ/m3)(MJ/m3)(MJ/m3)(MJ/m3)
May 2003 37.37.
April 2003 37.37.45
March 2003 37.37.37.45 37.
February 2003 37.48 37.37.45 37.
January 2003 37.48 37.37.45 37.48
Alberta/BC Border
Forecast HV Actual HV(MJ/m3) (MJ/m3)
37.
37.
37.
37.
37.
37.
37.
December 2002 37.44 37.48 37.45 37.45 37.37.
November 2002 37.37.37.45 37.46 37.37.
October 2002 37.41 37.48 37.45 37.46 37.37.
September
2002 37.37.44 37.37.37.37.80.
August 2002 37.44 37.49 37.37.37.37.82 .
July 2002 37.41 37.49 37.37.49 38.37.85 :
June 2002 37.41 37.37.45 37.37.38.~0 :
May 2002 37.41 37.37.37.48 37.37.
April 2002 37.37.47 37.37.37.37.
March 2002 37.43 37.45 37.37.37.37.
February 2002 37.37.37.37.37.37.
January 2002 37.44 37.43 37.37.37.37.
Border Archives
www.transcanada,com I Copyright (9 2003, TransCanada Pipelines LImited I Legal Notice
THIS PAGE INTENTIONALLY LEFT BLANK
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 13 of 23
Effective Rates and Charges for 2003
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 14 of 23
TransCan ada
1n buslfle!S'~ deliver
Commodity Rates at
Effective Heating Value Forecast of 37.93 MJ
FS-1 Firm Service Demand Rate (cents/GJ/Month/Km) 1.2188153197
FS-1 Firm Service Commodity Rate (cents/GJ/km) 0.0024087779
IS-1lnterruptible Service Commodity Rate (cents/GJ/km) * 0.0469317120
The IS-1lnterruptible SetVice Commodity Rate is calculated by taking .the FS-1 Firm ServiceDemand Rate at 90% load factor and adding the FS-1 Firm Service Commodity Rate.
Commodity Rates at
Baseline Conversion Rate of 37.8 MJ
FS-1 Firm Service Demand Rate (cents/GJ/Month/Km)
FS-1 Firm Service Commodity Rate (cents/GJ/km)
IS-1 Interruptible Service Commodity Rate (cents/GJ/km)
Rates Effective January 1, 2003
Expressed in Canadian Dollars and Cents
(MMBtu units expressed in US Dollars)
Firm Service (FS-
Demand Rate
Commodity Rate
Total FS-1 Rate (Kingsgate)
Interruptible Service (IS-
Interruptible Commodity Rate
TotallS-1 Rate (Kingsgate)
(Cdn cents)
0.41
(Cdn cents)
1. Tolls are payable in Canadian dollars and
GJ units are used for billing puposes.
2. Posted commodity rates are based on Effective Heating Value
Forecast or 37.8 GJ/E3
3. Conversion factors $Cdn to $U.S. divide by 1.53 (subject to change)
cents/GJ to cents/MMBtu multiply by 1.055056.
4. The 2002 average fuel ratio to Kingsgate is forecast at 1.2%.5. All rates are based on 100% load factor utilization except for
interruptible which is at a 90% load factor.6. All rates do not include a provision for GST.
www.transcanada.com I Copyright iG) 2003, TransCanada PipeLInes Limited I Legal Notice
Toll Rate
. Toll Rate
2188153197
0024170621
0469399961
MMBtu
(US cen~s)
. 0.
MMBtu
(US cents)
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 15 of 23
((~
TransCanada
In bus~ to deliver ThO
Current Fuel Rates & Heating Values
April 23, 2003
Fuel Rate and MJ value on TransCanada s B.C. System for May, 2003
Please be advised that effective May 1 , 2003 the fuel rate on TransCanada s B.C. System will change to 0.and the heat content posted at Kingsgate will change to at 37.92 MJ. '
If you have any questions please contact Lisa Draudson at 403.920.5593.
Path Kilometer Post % Fuel Rate Per GJ
Alberta/B.C. Interconnect to:
Sparwood Sales Tap 05008787
Byron Creek Sales Tap 18.09595782
Fernie Sales Tap 53.2831283
Elko Sales Tap 69.36748682
Galloway Sales Tap 85.0.44815466
Cranbrook Sales Tap 99.52249561
Yahk Sales Tap 156.4 82460457
East Kootenay Exchange 162.4 85623902Kingsgate Meter Station 170.
East Kootenay to:
Kingsgate Meter Station 04376092
For the period of May 1 , 2003, until further notice, a fuel rate of .0052724% per GJ/km will be in effect. Applicableper GJ/km rates for the most common paths are provided above.
www.transcanada.com I Copyright (S) 2003, TransCanada PipeLInes LImited I Legal Notice
. ,
THIS PAGE INTENTIONALLY LEFT BLANK
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 16 of 23
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 17 of 23
PG&E Gas Transmission, Northwest Corporation
FERC Gas Tariff
Second Revised Volume No. 1-A Third Revised Sheet No.
Superseding
Second Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-1 and LFS-1
RESERVATION DELIVERY (c)
(Dth-MILE)
FUEL (d)
(Dth)MILEAGE (a)
(Dth/MILE)
NON-MILEAGE (b)
(Dth)
MAX I MUM MINIMUM MAX I MUM MINIMUM . MAXIMUM MINIMUM MAXIMUM MINIMUM
BASE 011212 000000 884028 000000"'0.000013 000013 0050% 0.0000%
MRRS (e) 0.000227 000000 049280 0000"00
CES 000227 000000 049280 000000
EXTENSION CHARGES
MEDFORD
E-1 (f) 0.296969 0.000000 000016 0.000016
E-2 (g) 0.192258 0.000000
(WWP)
000000 0.000000
E-2 (h) 0.090388 0.000000
(Diamond 1)000000 O. O~OOOO
2(h) 0.035477 0.000000
(Diamond 2)000000 0.000000
COYOTE SPRINGS
E-3(i) 0.064705 0.00000 000000 000000
OVERRUN CHARGE (j )
SURCHARGES
ACA (k)
GRI (m)
HLF
LLF
002100 002100
050000 000000 004000 000000031000000000004000000000
Issued by: John A Roscher, Director of Rates & Regulatory AffairsIssued on: November 22, 2002 Effective on: January 1, 2003
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 18 of 23
PG&E Gas Transmission, Northwest CorporationFERC Gas Tariff Second Revised Sheet No.
Second Revised Volume No. I-Superseding
Alternate First Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND C~GES
FOR TRANSPORTATION OF NATURAL GAS
Notes:
(a) The mileage component shall be applied per pipeline mile to gas
transported by PG&E GT-NW for delivery to shipper based on the primary
receipt and delivery points in Shipper's contract. Consult PG&E GT-NW'
system map on Sheet 3 for receipt and delivery point and milepost
designations.
(b) The non-mileage component is applied per- Shipper's MDQ at PrimaryPoint (s) of Delivery on Mainline Facilities.
. (c) The delivery rates are applied per pipeline mile to gas transported by
PG&E GT-NW for delivery to shipper based on distance of gas transported.
Consult PG&E GT-NW's system map on Sheet No.3 for receipt and delivery
point and milepost designations.
(d) Fuel Use: Shipper shall furnish gas used for compressor station fuel,
line loss, and other utility purposes, plus other uhacco~nted-for gas
used in the operation of, PG&E GT-NW's combined pipeline system in an
amount equal to the sum of the current fuel and line loss percentage and
the fuel and line loss percentage surcharge in accordanc~ with Paragraph
37 of this tariff, multiplied by the distance in pipelin~ miles
transported from the receipt point to the delivery point 'multiplied by
the transportation quantities of gas received from Shipper under these
rate schedules. The current fuel and line loss percentage shall be
adjusted each month between the maximum rate of 0.0050% per Dth per
pipeline mile and the minimum rate of 0.0000% per Dth per mile. The
fuel and line loss percentage surcharge is 0.0000% per Dth per pipeline
mile. No fuel use charges will be assessed for backhaul service; The
incremental fuel surcharge for Shippers utilizing capacity constructed
as part of PG&E GT-NW's 2002 Pipeline Expansion Project is O. 000~28% perDth per pipeline mile.
(e) The MRRS Surcharge applies to Subject Shippers pursuant to Paragraph
1 (c) of Rate Schedule FTS-1 and Article IV, Section 1 (c) of the
Stipulation and Agreement in Docket No. RP94-149-000.
(f) Applicable to firm service on PG&E GT-NW's Medford Extension.
(Continued)
Issued by: John A Roscher, Director of Rates & Regulatory AffairsIssued on: November 22, 2002 Effective on: January 1, 2003
Next Search
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 19 of 23Previous
PG&E Gas Transmission, Northwest CorporationFERC Gas Tariff Second Revised Sheet No.Second Revised Volume No. I-A Superseding
Alternate First Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes:
(a) The mileage component shall be applied per pipeline mile to gas
transported by PG&E GT-NW for delivery to shipper based on the primary
receipt and delivery points in Shipper's contract. Consu~t PG&E GT-NW'system map " on Sheet 3 for receipt "and delivery point and milepostdesignations.
(b) The non-mileage component is applied per Shipper's MDQ at Primary
Point (s) of Delivery on Mainline Facilities.
(c) The delivery rates are applied per pipeline mile to gas transported by
PG&E GT-NW for delivery to shipper based on distance of gas transported.Consul t PG&E GT-NW' s system map on Sheet No.3 for receipt and deliverypoint and milepost designations.
(d) Fuel Use: Shipper shall furnish gas used for compressor station fuel
line loss, and other utility purposes, plus other unaccounted-for gasused in the operation of PG&E GT-NW I s combined pipeline system in anamount equal to the sum of the current fuel and line loss percentage and
the fuel and line loss percentage surcharge in accordance with Paragraph
37 of this tariff, multiplied by the distance in pipeline miles
transported from the receipt point to the delivery point multiplied by
the transportation quanti ties of gas received from Shipper under these
rate schedules. The current fuel and line loss percentage shall be
adjusted each month between the maximum rate of 0.0050% per Dth perpipeline mile and the minimum rate of 0.0000% per Dth per mile. Thefuel and line loss percentage surcharge is 0.0000% per Dth per pipelinemile. No fuel use charges will be assessed for backhaul service. Theincremental fuel surcharge for Shippers utilizing capacity constructed
as part of PG&E GT-NW I s 2002 Pipeline Expansion Project is 0.000928% perDth per pipeline mile.
(e) The MRRS Surcharge applies to Subject Shippers pursuant to Paragraph
1(c) of Rate Schedule FTS-l and Article IV , Section l(c) of theStipulation and Agreement in Docket No. RP94-149-000.
(f) Applicable to firm service on PG&E GT-NW's Medford Extension.
(Continued)
THIS PAGE INTENTIONALLY LEFT BLANK
Exhibit No.
Case No. INT-03-
Intermountain Gas Company
Page 20 of 23
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 21 of
QUEST.R
Queste. Pipeline C;:ompaity
180 East 100 South
P.O. Box 45360
Salt lake City, UT 84145-0360
Tel [phone]
April I?, 2003
David Swenson
Intermountain Gas
555 S. Cole Road
P. O. Box 7608
Boise, ill 83707
Dear Mr. Swenson:
Attached are Questar Pipeline Company s FERC Gas Tariff Fourteenth Revised Sheet
No.effective as of October 1, 2002, and Nmtb Revised Sheet No. 6A, effective as of March, 2001. '
Please let me know if you need additional information.
Sincerely,
UJ' ff~
Phyllis W. Hansen
Associate Regulatory Affairs Analyst
Questar Pipeline Company
[phone]
[phone] (FAX)
Phyllisb(g)questar. com
Questar Pipeline Company
FERC Gas Tariff",f ~~+-
...~ ,
STATEMENT OF RATES
Rate Schedule/
Twe of charlie(a)
PEAKING STORAGE
Monthly Reservation Charge
Maxlnun
Mlnlnun
Usage ChargeInjection
III thdrawa l
Base
Tariff
Rate(ij)
87375 Y
00000
03872
03872
CLAY BASIN "STORAGE
Firm Storage Service. FSS
Monthly Reservation Charge
Deliverabil Ity
Maxi nun
Mininun
Capacity
Maxinun
Mlnlnun
85338 Y
00000
02318
00000
Usage Charge
Injection
IIlthdrawal
Authorized OVerrUn Charge
Maxlnun
Minlnun
01049
01181
30315
01181
Interruptible Storage Service - ISS
Usage Charge
Inventory
Maxi1lun
MlninunInjection
IIlthdrawal
05927
00000
01049
01181
OPTIONAL VOLUMETRIC RELEASES
Peaking Storage Service. PKS
Maxinun
Mlnlnun 40890
00000
Firm Storage Service. FSS
Maxinun
Mlnlnun 57068
00000
Storage Usage Charges Appll cable to Volunetrlc Releases
Peaking Storage Service- PKS:Injection 0.03872IIithdrawal 0.03872
Clay Basin Storage Service - FSS:
Injection
Withdrawal 01049 '
01181
PARK AND LOAN SERVICE - PAU
Daily Reservation Charge
Maxlnun
Minlnun
Usage Charge
30315
00000
02830
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 22 of 23
Fourteenth Revised Sheet No.
Supersedingft~-.f ft_'" ..,,--+- ...- t;.
AnnulI l
Charge
Adjustment
(c)
00212
00212
00212
00212
00212
00212
' Currently
Effective
Rate
(d)
87375/Dth
OOOOO/Dth
03872/Dth
O3872/Dth
85338/Dth
OOOOO/Dth
O2318/Dth
OOOOO/Dth
01261/Dth
01181/Dth
30527/Dth
01993/Dth
05927/Dth
OOOOO/Dth
01261/Dth
01181/Dth
40890/Dth
OOOOO/Dth
57068/Dth
OOOOO/Dth
03872/Dth
03872/Dth
01261/Dth
01181/Dth
30315/Dth
OOOOO/Dth
03O42/Dth
FUEL REIMBU~SEMENT - 2.0" (0.2" utility and 1.8" cClq)ressor fuel) for Rate Schedule PAL1
Issued By:
Issued On:
K. Allred, Senior Vice President
August 27, 2002
Effective: October 1, 2002
Exhibit No.
Case No. INT-O3-
Intermountain Gas Company
Page 23 of 23
Questar Pipeline Company
FERC Gas Tariff
"': --.. ",- ,
Ninth Revised Sheet No. 6A
Superseding
- ."..__.. ",- ,:;"
FOOTNOTES
, ,
YShipj)er may request service in excess of its MRD and Questar may provide the service if
capacity is available.
YAwl ied to the average monthly working gas balance.
VReleased capacity may be sold at a volunetrlc rate. Shippers releasing capacity on a
volunetric basis I1I.ISt specify a rate between the IIBxillUR and mininun volunetric rate stated on this
Statement of Rates and notify Questar of the criteria by w!!ich bids sre .to be evaluated; providedhowever, that the bid may exceed the otherwise sppl Icsbl~lIBxinun rate to the extent the rateceil ings have been waived for released capacity trBnSacticii\s of less then one year, as described infootnote 6.
YStorage usage charges are appl icable to storage services that are released at a volunetricrate and wi I I be bl I led to the replacement shipper according to S 18.2 of the General Terms and
Conditions of Part 1 of this tariff.
~The amual charge adjustment (ACA) as specified by the Conmlssion will be ,billed according
to is 4(f) and 3(d) of Rate Schedule FSS and ISS, respectively, and S 17 ~f the General Terms and
Conditions of Part 1 of this tariff.
The maxinun rate ceil ing was waived by Conmlssion Order No. 637, issueC! February 9, 2000for short-term releases of capacity of less than one year beglming March 26, 2000, extending
through Septenber 30, 2002, pursuant to 18 C.R. S 284.8(i).
NOTE: The monthly rates stated on Questar's Statement of Rates IIBY be ,converted to a dai Iy
rate by IIIJltiplying the monthly base tariff rate times the I1UIber of months In the rate period and
dividing the result by the I\Uli)er of days in the rate period. The result is rounded to the fourthdecimal place.
Issued By:
Issued On:
X. Allred, VP, Business Development
February 20, 2001 Effective: March 23, 2001
EXIllBIT NOS. 4-
CASE NO. INT -G-03-
INTERMOUNTAIN GAS COMPANY
(11 pages)
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Exhibit No.1 0
Case No. INT-O3-
Intermountain Gas Company
INTERMOUNTAIN GAS COMPANY Page 1 of
Proposed Temporary Surcharges (Credits). Variable Costs
Description
(a)
Amount
(b)
Account 1860 Amounts Which Apply to RS., RS., GS., and LV.
Account 1860 Variable Costs (1)
Normalized Sales/CD Vois. (10/1/01 - 9/30/02)
Proposed Temporary Surcharge(Credit) . Variable Costs
$ 4,427 982
260 347 643$ 0.01701
(1) See Workpaper No.6, Page 1 , Line 21 , Col (n
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J
.
EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX: [phone]
NEWS RELEASE Contact: Mike Huntington
Vice President
Marketing & External Affairs
[phone]May 7, 2003
TODAY, INTERMOUNTAIN GAS COMPANY ("INTERMOUNTAIN") FILED ITS ANNUAL PURCHASED GAS COST ADJUSTMENT
APPLICATION WITH THE IDAHO PUBLIC UTILITIES COMMISSION ("IPUC"). THIS TYPE OF APPLICATION IS FILED EACH YEAR TO
ENSURE THAT THE COSTS THAT INTERMOUNTAIN IS INCURRING ON BEHALF OF ITS CUSTOMERS ARE PROPERLY REFLECTED IN ITS
SALES PRICE.
IN ITS APPLICATION, INTERMOUNTAIN REQUESTS PERMISSION TO INCREASE ITS PRICES TO REFLECT THE HIGHER PRICES
THAT INTERMOUNTAIN MUST PAY TO ITS NATURAL GAS SUPPLIERS.
WILLIAM C. "BILL" GLYNN, PRESIDENT OF INTERMOUNTAIN GAS COMPANY, SAID
, "
NATURAL GAS IS A COMMODITY
WHOSE PRICE FLUCTUATES AS SUPPLY AND DEMAND CHANGES, JUST LIKE THE PRICE OF OTHER COMMODITIES, MOST NOTABLY
POTATOES HERE IN IDAHO. AFTER ENJOYING PRICES THIS PAST WINTER THAT WERE APPROXIMATELY 30% BELOW YEAR EARLIER
PRICES, PRODUCER PRICES HAVE INCREASED. WE EXPECT ANOTHER DOWN CYCLE TO OCCUR BUT IT IS UNCERTAIN AS TO
WHETHER THIS WILL OCCUR BEFORE NEXT WINTER. SHOULD THEY CHANGE BEFORE THEN, THE COMPANY WILL ASK THE IPUC TO
ADJUST OUR RETAIL PRICE ACCORDINGLY.
GLYNN SAID, .. EVEN AT THESE HIGHER PRODUCER PRICES, NATURAL GAS IN SOUTHERN IDAHO WILL STILL BE 35% - 55%
LESS THAN ELECTRICITY.
THE COMPANY IS NOT REQUESTING ANY CHANGE IN THE PRICE COMPONENT FOR ITS OWN SERVICE, OPERATION
MAINTENANCE, OR CAPITAL COSTS, WHICH HAS REMAINED THE SAME FOR ALMOST 20 YEARS. THEREFORE THE COMPANY'
EARNINGS WILL NOT INCREASE AS A RESULT OF THE PROPOSED PRICE CHANGES.
GLYNN WENT ON TO SAY, "ALTHOUGH WE HAVE JUST EXPERIENCED THE WARMEST WINTER ON RECORD IN THE PAST 30
YEARS, INTERMOUNTAIN ENCOURAGES ALL ITS CUSTOMERS TO BE CONSCIOUS OF THEIR ENERGY USAGE. WE CONTINUE TO WORK
WITH THE LOCAL AGENCIES THAT ADMINISTER ENERGY ASSISTANCE FUNDS TO HELP THOSE RESIDENTIAL CUSTOMERS WHOSE
INCOMES ARE MOST IMPACTED BY HIGHER ENERGY PRICES. HELPFUL TIPS ON WAYS TO CONSERVE AND USE ENERGY WISELY AND
HOW TO REQUEST ENERGY ASSISTANCE ARE PROVIDED THROUGH BILL INSERTS AND ON THE COMPANY'S WEB SITE
www.intqas.com
IF THIS PROPOSED INCREASE IS APPROVED, RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR HEATING AND WATER
HEATING COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $18 (38%). THOSE RESIDENTIAL CUSTOMERS USING NATURAL
GAS FOR SPACE HEATING ONLY COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $12 (33%). COMMERCIAL CUSTOMERS
COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $78 (43%).
IF APPROVED AS FILED, THE TOTAL NET REVENUE INCREASE FROM THIS CURRENT REQUEST WILL BE APPROXIMATELY $61
MILLION (38%) AND IS PROPOSED TO BE EFFECTIVE JULY 1, 2003. THIS PROPOSAL IS SUBJECT TO PUBLIC REVIEW AND
APPROVAL BY THE IPUC. A COpy OF INTERMOUNTAIN'S APPLICATION IS AVAILABLE AT THE OFFICES OF BOTH THE IDAHO PUBLIC
UTILITIES COMMISSION AND THE COMPANY.
EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX: [phone]
CUSTOMER NOTICE
ON MAY 7,2003, INTERMOUNTAIN GAS COMPANY ("INTERMOUNTAIN") FILED ITS ANNUAL PURCHASED GAS COST
ADJUSTMENT APPLICATION WITH THE IDAHO PUBLIC UTILITIES COMMISSION ("IPUC"). THIS TYPE OF APPLICATION IS FILED EACH
YEAR TO ENSURE THAT THE COSTS THAT INTERMOUNTAIN IS INCURRING ON BEHALF OF ITS CUSTOMERS ARE PROPERLY REFLECTED
IN ITS SALES PRICE.
IN ITS APPLICATION, INTERMOUNTAIN REQUESTS PERMISSION TO INCREASE ITS PRICES TO REFLECT THE HIGHER PRICES
THAT INTERMOUNTAIN MUST PAY TO ITS NATURAL GAS SUPPLIERS.
WILLIAM C. "BILL" GLYNN , PRESIDENT OF INTERMOUNTAIN GAS COMPANY, SAID, "NATURAL GAS IS A COMMODITY
WHOSE PRICE FLUCTUATES AS SUPPLY AND DEMAND CHANGES, JUST LIKE THE PRICE OF OTHER COMMODITIES, MOST NOTABLY
POTATOES HERE IN IDAHO. AFTER ENJOYING PRICES THIS PAST WINTER THAT WERE APPROXIMATELY 30% BELOW YEAR EARLIER
PRICES, PRODUCER PRICES HAVE INCREASED. WE EXPECT ANOTHER DOWN CYCLE TO OCCUR BUT IT IS UNCERTAIN AS TO
WHETHER THIS WILL OCCUR BEFORE NEXT WINTER. SHOULD THEY CHANGE BEFORE THEN, THE COMPANY WILL ASK THE IPUC TO
ADJUST OUR RETAIL PRICE ACCORDINGLY.
GLYNN SAID
, "
EVEN AT THESE HIGHER PRODUCER PRICES, NATURAL GAS IN SOUTHERN IDAHO WILL STILL BE 35% - 55%
LESS THAN ELECTRICITY.
THE COMPANY IS NOT REQUESTING ANY CHANGE IN THE PRICE COMPONENT FOR ITS OWN SERVICE, OPERATION,
MAINTENANCE, OR CAPITAL COSTS, WHICH HAS REMAINED THE SAME FOR ALMOST 20 YEARS. THEREFORE THE COMPANY'
EARNINGS WILL NOT INCREASE AS A RESULT OF THE PROPOSED PRICE CHANGES.
GLYNN WENT ON TO SAY
, "
ALTHOUGH WE HAVE JUST EXPERIENCED THE WARMEST WINTER ON RECORD IN THE PAST 30
YEARS, INTERMOUNTAIN ENCOURAGES ALL ITS CUSTOMERS TO BE CONSCIOUS OF THEIR ENERGY USAGE. WE CONTINUE TO WORK
WITH THE LOCAL AGENCIES THAT ADMINISTER ENERGY ASSISTANCE FUNDS TO HELP THOSE RESIDENTIAL CUSTOMERS WHOSE
INCOMES ARE MOST IMPACTED BY HIGHER ENERGY PRICES. HELPFUL TIPS ON WAYS TO CONSERVE AND USE ENERGY WISELY AND
HOW TO REQUEST ENERGY ASSISTANCE ARE PROVIDED THROUGH BILL INSERTS AND ON THE COMPANY'S WEB SITE
www.intqas.com
IF THIS PROPOSED INCREASE IS APPROVED, RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR HEATING AND WATER
HEATING COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $18 (38%). THOSE RESIDENTIAL CUSTOMERS USING NATURAL
GAS FOR SPACE HEATING ONLY COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $12 (33%). COMMERCIAL CUSTOMERS
COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $78 (43%).
IF APPROVED AS FILED, THE TOTAL NET REVENUE INCREASE FROM THIS CURRENT REQUEST WILL BE APPROXIMATELY $61
MILLION (38%) AND IS PROPOSED TO BE EFFECTIVE JULY 1 , 2003. THIS PROPOSAL IS SUBJECT TO PUBLIC REVIEW AND
APPROVAL BY THE IPUC. A COpy OF INTERMOUNTAIN S APPLICATION IS AVAILABLE AT THE OFFICES OF BOTH THE IDAHO PUBLIC
UTILITIES COMMISSION AND THE COMPANY.
WORKPAPERNOS.
CASE NO. INT -G-03-
INTERMOUNTAIN GAS COMPANY
(9 pages)
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Northwest Pipeline TF.1 Full Rate Demand Workpaper
Line INT-02-INT-02-INT-02-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 412 537 600 02862 806 826
TF-1 Demand 1 Contract #2 25,550 000 02862 731 241
TF-1 Demand 1 Contract #3 000,000 02862 089 260
TF-1 Demand 1 Contract #4 23,542 500 02862 673 786
TF-1 Demand 1 Contract #5
Total Annual Cost 534,630 100 02862 15,301,113
INT-03-INT-03-INT-03-
Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 412 537 600 02862 11,806,826
TF-1 Demand 1 Contract #2 25,550,000 02862 731 241
TF-1 Demand 1 Contract #3 73,000,000 02862 089 260
TF-1 Demand 1 Contract #4 542 500 02862 673,786
TF-1 Demand 1 Contract #5 100,000 02862 346,302
Total Annual Cost 546,730,100 02862 647,415
Total Annual Cost Difference 346,302 (1)
(1) See Exhibit 4, Line 3, Column (h)
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Northwest Pipeline TF.1 Discounted Demand Workpaper
Line INT-02-INT-02-INT-02-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract#1 87,600 000 01623 1,421 748
TF-1 Demand 1 Contract#2 28,470 000 01679 478 011
TF-1 Demand 1 Contract #3 29,404,400 01371 403 134
TF-1 Demand 1 Contract #4 150,000 13987 170,980
TF-1 Demand 1 Contract #5
TF-1 Demand 1 Contract #6
Total Annual Cost 145,624,400 01699 2,473,873
INT-03-INT-03-INT-03-
Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract#1 43,680,000 02792 219 546
TF-1 Demand 1 Contract #2 28,470,000 01675 476,873
TF-1 Demand 1 Contract #3 29,404,400 01481 435,479
TF-1 Demand 1 Contract#4
TF-1 Demand 1 Contract#5 650,000 01675 379,388
TF-1 Demand 1 Contract #6 24,200,000 01173 283,866
Total Annual Cost 148,404,400 01883 795 152
Total Annual Cost Difference 321 279 (1)
(1) See Exhibit 4, Line 4, Column (h)
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Upstream Capacity Workpaper
Line INT-02-INT-02-INT-02-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
Upstream Capacity #1 181 258 720 $ 0.01067 934,483
Upstream Capacity #2 138,819,721 00466 647,497
Upstream Capacity #3 155,025,220 01642 545,358
Total Upstream Capacity 475,103,661 $ 0.01079 127,338
INT-03-INT-03-INT-03-
Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
Upstream Capacity #1 200,713,500 01060 127 563
Upstream Capacity #2 155 624 370 00477 742 328
Upstream Capacity #3 155,025,220 01349 091,290
Total Upstream Capacity 511,363,090 00970 961,181
Total Annual Cost Difference (166,157) (1)
(1) See Exhibit 4, Line 5, Column (h)
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Other Storage Facilities
INT-02-
Line Monthly INT-02-INT-02-3 INT-G-O2-
No.Stora e Facilities Billina Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(d)(d)
Demand Costs.
Clay Basin I Reservation 266,250 (1)28534 971 911 655
Clay Basin II Reservation 221,880 (1)28534 63,311 759 730
Clay Basin I Capacity 31,950 000 (2)00238 75,977 911 725
Clay Basin II Capacity 625 000 (2)00238 63,314 759,771
AECO I Demand 530,350 (2)00159 13,576 162,912
AECO II Demand 26,064 970 (2)00108 28,137 337 644
Total Demand Costs 93,170,320 (3)320 286 843,437
Cycling Costs -
Clay Basin Cycling Costs 58,575 000 00064 526 450 308
AECO Cycling Costs 34,595 320 00070 107 289 286
Total Cycling Costs 93,170,320 61,633 739 594
Storage Demand Charge Credit 489 000
Total Costs Including Storage Credit 094 031
INT-03-
Monthly INT-03-INT-03-INT-03-
Stora e Facilities Billina Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(d)(d)
Demand Costs -
Clay Basin I Reservation 266,250 (1)28530 75,961 911,532
Clay Basin II Reservation 221 840 (1)28534 63,300 759,600
Clay Basin I Capacity 950,000 (2)00238 76,041 912,492
Clay Basin II Capacity 26,625 000 (2)00238 63,368 760,416
AECO I Demand
AECO II Demand 26,064 970 (2)00109 28,411 340 932
Total Demand Costs 84,639,970 (3)307,081 684,972
Cycling Costs.
Clay Basin Cycling Costs 58,575,000 00076 44,517 534 204
AECO Cycling Costs 064 970 00074 288 231,456
Total Cycling Costs 639 970 63,805 765 660
Storage Demand Charge Credit 390,700
Total Costs Including Storage Credit 059,932
Total Annual Cost Difference including Storage Credit (34 099) (4)
(1) Charge Based on Maximum Daily Withdrawal
(2) Charge Based on Maximum Contractual Capacity
(3) Non Additiye Billing Determants; Only Includes Capacity Volumes
(4) See Exhibit 4, Line 19, Column (h)
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators in Case No. INT -O3-
FIRM
Line CORE TOTAL TRANSPORTATION TOTAL FIRM
No.RS.RS.GS.CORE TRANSPORTATION
DEMAND ALLOCATORS PER CASE NO. INT.O2.
Peak Day Therms 427,136 1,410,959 045,771 883 866 223,406 55,070 278,476
% oITota!91.19399%1.illm 80600%
TOTAL
PEAK
162 342
PROPOSED DEMAND ALLOCATORS PER CASE NO.INT.O3.:
Peak Day Therms (Line 2)427 136 1,410,959 045 771 883,866
Customers Embedded within Line 2 991 145 911 394 230,296
Peak Day Usage Per Customer (Line 5 divided by Line 6)42.
January 2003 Actual Customers 024 155,427 937 241,388
INT-G-03- Peak Day Therms (Line 7 mulitplied by Line 8)434,491 502,979 069,049 006,519 199,616 55,070 254 686 (1)261 205
% of Total 92.19043%80957%
(1) FY03 Contract Therms
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
INTERMOUNTAIN GAS COMPANY Page 1 of 3
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2003
Line
No.Description Detail Detail Amount Sub-Total Total
(a)(b)(c)(d)(e)(I)
ACCOUNT 1860 VARIABLE AMOUNTS:
Net Cumulative Deferred Gas Balance in 1860.2010 as of 7/1/02 (6,295,055.05)
Amortization in 1860.2020 as of 3/31/03 408,393.
Estimated Therrn Sales 4/1 through 6/30/03 504 610
Amortization Rate 02473 248,979.
Estimated Amortization In 1860.2020 at 6/30/03 657 372.
Estimated Balance in 1860.2010 at 6/30/03 (637 682.09)
Deferred Gas Costs From Producers/Suppliers In 1860.2180 at 7/1102 (64 139.91)
Deferred Gas Costs From Producers/Suppliers in 1860.2180 through 3/31/03 307,774.
Estimated Deferred Costs in 1860.2180 from 4/1 through 6/30/03 836,478.
Estimated Balance in 1860.2180 at 6/30/03 080 112.48
Daily Gas Excess Sales Deferred in 1860.2240 at 3/31/03
Gas Cost Carrying Charge Deferred In 1860.2340 at 3/31/03 (19 563.17)
Estimated Gas Cost Carrying ChallJe from 4/1 through 6/30/03 114.
Estimated Balance in 1860.2340 at 6/30/03 (14,448.48)
ESTIMATED ACCOUNT 1860 VARIABLE BALANCE AT 6/30/03 427,981.91
ACCOUNT 1860 FIXED AMOUNTS:
Net Cumulative Deferred Gas Balance in 1860.2050 at 7/1/02 116,072.
RS-1 Deferred Gas Balance In 1860.2060 at 7/1/02 185.
Amortization for RS-1 in 1860.2060 at 3/31/03 (148 319.35)
Estimated RS-1 Therrn Sales 4/1 through 6/30/03 293,829
RS-1 Amortization Rate (0.00567)(35 686.02)
Estimated RS-1 Balance in 1860.2060 at 6/30/03 (183819.59)
RS-2 Deferred Gas Balance in 1860.2070 at 7/1/02 (424.07)
Amortization for RS-2 in 1860.2070 at 3/31/03 186,116.
Estimated RS-2 Therrn Sales 4/1 through 6/30/03 26,521,322
RS-2 Amortization Rate 00188 860.
Estimated RS-2 Balance In 1860.2070 at 6/30/03 235,552.
GS-1 Deferred Gas Balance in 1860.2080 at 7/1/02 359.
Amortization for GS-1ln 1860.2080 at 3/31/03 (131 265.45)
Estimated Therm Sales 4/1 through 6/30/03 011 759
GS-1 Amortization Rate (0.00198)(33,683.29)
Estimated GS-1 Balance In 1860.2080 at 6/30/03 (164 588.89)
Industrial Deferred Gas Balance in 1860.2090 at 7/1/02 822.
Amortization for T-1 & T-2 in 1860.2090 at 3/31/03 $26,763.
Estimated T-1 Block 1 & 2 Therrn Sales 4/1 through 6/30/03 073,897
1 Amortization Rate 00031 502.
Estimated T-2 Contract 4/1 through 6/30/03 165 210
2 Amortization Rate 03706 122.
Estimated Industrlal Balance In 1860.2090 at 6/30/03 36,212.
Estimated Cumulative Balance in 1860.2050 at 6/30/03 39,428.
Fixed Cost Collection Deferred in 1860.2200 at 7/1/02 632,471.
Fixed Cost Collection Deferred in 1860.2200 through 3/31/03 561,435.47
Estimated Fixed Cost Collection Deferred from 4/1 through 6/30/03 023 527.49
Estimated Balance in 1860.2200 at 6/30/03 217,434.
T.4 Exit Fee Adjustment Deferred In 1860.2210 at 7/1/02 (1.47)
4 Exit Fee Adjustment Deferred in 1860.2210 through 3/31/03 (262.80)
Estimated T -4 Exit Fee Adjustment Deferred from 4/1 through 6/30/03
Estimated Balance in 1860.2210 at 6/30/03 (264.27)
Statoil Revenue Deferred in 1860.2260 at 7/1102 (574.14)
Statoil Revenue Deferred in 1860.2260 through 3/31/03 (42 946.80)
Estimated Statoll Revenue Deferred from 4/1 through 6/30/03 (12 101.15)
Estimated Balance in 1860.2260 at 6/30/03 (55,622.09)
Capacity Released/Purchased Deferred in 1860.2320 at 3/31/03 (481 576.17)
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
INTERMOUNTAIN GAS COMPANY Page 2 of 3
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2003
Line
No.Description Detail Detail Amount Sub.Total Total
(a)(b)(c)(d)(e)(f)Gas Cost Carrying Charge Deferred in 1860.2420 at 3/31/03 (281.27)
Estimated Gas Cost Carrying Charge from 4/1 through 6/30103 (17.46)
Estimated Balance In 1860.2420 at 6/30/03 (298.73)
Gas Cost Carrying Charge Deferred In 1860.2430 at 3/31/03 636.
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/03 091.
Estimated Balance In 1860.2430 at 6/30/03 727.
NWP RP93.5 Surcharge Deferred in 1860.2500 at 3/31/03 895 201.
Estimated Deferral In 1860.2500 from 4/1 through 6/30103
Estimated Balance In 1860.2500 at 6/30103 895,201. 73
RS-1 Amortization In 1860.2510 at 3/31/03 (116 187.03)
Estimated RS-1 Therm Sales from 4/1 through 6/30/03 293 829
RS-1 Amortization Rate (0.00445)(28,007.54)
Estimated RS-1 Amortization In 1860.2510 at 6/30/03 (144 194.57)
RS-2 Amortization In 1860.2510 at 3/31/03 (309 995.45)
Estimated RS-2 Therm Sales from 4/1 through 6/30/03 521 322
RS-2 Amortization Rate (0.00316)(83,807.38)
Estimated RS-2 Amortization In 1860.2510 at 6/30103 (393 802.83)
GS-1 Amortization In 1860.2510 at 3/31/03 (252,462.28)
Estimated GS Therm Sales from 4/1 through 6/30103 17,011,759
GS-1 Amortization Rate (0.00375)(63 794.10)
Estimated GS-1 Amortization In 1860.2510 at 6/30103 (316,256.38)
Estimated Balance In 1860.2500 at 6/30/03 40,947.
Market Segmentation Deferred In 1860.2530 at 7/1/02 804.
Market Segmentation Deferred In 1860.2530 through 3/31/03 777,801.85)
Estimated Deferral In 1860.2530 from 4/1 through 6/30103 (590,439.00)
Estimated Balance in 1860.2530 at 6/30103 366,436.76)
RS-1 Amortization In 1860.2540 at 3/31/03 235,186.
Estimated RS-1 Therm Sales from 4/1 through 6/30/03 293 829
RS-1 Amortization Rate 00899 56,581.52
Estimated RS-1 Amortization In 1860.2540 at 6/30103 291,767.
RS-2 Amortization In 1860.2540 at 3/31/03 850,411.
Estimated RS-2 Therm Sales from 4/1 through 6/30103 26,521,322
RS-2 Amortization Rate 00857 227 287.
Estimated RS-2 Amortization In 1860.2540 at 6/30103 077 699.
GS-1 Amortization in 1860.2540 at 3/31/03 579,611.
Estimated GS Therm Sales from 4/1 through 6/30103 011,759
GS-1 Amortization Rate 00847 144 089.
Estimated GS-1 Amortization In 1860.2540 at 6/30103 723 701.50
Estimated Core Amortization In 1860.2540 at 6/30103 093,168.
1 Amortization In 1860.2550 at 3/31/03 117 583.
Estimated T-1 Block 1&2 Therm Sales from 4/1 through 6/30103 073 897
1 Amortization Rate 00441 35,605.
Estimated T-1 Amortization In 1860.2550 at 6/30103 153,189.
2 Amortization In 1860.2550 at 3/31/03 29,346.
Estimated T-2 Contract from 4/1 through 6/30103 165,210
2 Amortization Rate 05921 782.
Estimated T-2 Amortization In 1860.2550 at 6/30103 128.
Estimated Indusliial Amortization In 1860.2550 at 6/30103 192,317.40
Estimated Balance In 1860.2530 at 6/30/03 (80,950.83)
LIneNo. Description
(a)
NWP RP95.409 Refund Deferred In 1860.2560 at 3/31/03
EsUmated Deferral In 1860.2560 from 4/1 through 6/30/03
Estimated Balance In 1860.2560 at 6/30/03
RS-1 Amortization In 1860.2510 at 3/31/03
Estlmated RS-1 Therm Sales from 4/1 through 6/30/03
RS-1 Amortizatlon Rate
Estimated RS.1 Amortization In 1860.2510 at 6/30/03
RS-2 Amortization In 1860.2510 at 3/31/03
Estimated RS-2 Therm Sales from 4/1 through 6/30/03
RS-2 Amortization Rate
Estimated RS-2 Amortizatlon In 1860.2510 at 6/30/03
GS.1 Amortization in 1860.2510 at 3/31/03
Estimated GS Therm Sales from 4/1 through 6/30/03
GS-1 Amortizatlon Rate
Estimated GS-1 Amortizatlon In 1860.2510 at 6/30/03
Estimated Balance in 1860.2560 at 6/30/03
ESTIMATED ACCOUNT 1860 FIXED BALANCE AT 6/30/03
TOTAL DEFERRED ACCOUNT 1860 BALANCE
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2003
Detail
(b)
Detail
(c)
385 551.00)
406,001.85
293,829
01555 869.
624 895.
26,521,322
00637 168,940.
760 753.
011 759
01130 192,232.
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 3 of 3
Amount
(d)
Sub.Total
(e)
Total
(I)
(2,385 551.00)
503,870.
793,836.
952,985.
(134 857.43)
556,969.
984,951.10
INTERMOUNTAIN GAS COMPANY
1 Tariff Block 1 , Block 2, and Block 3 Adjustment
Line
No.Description
(a)
Industrial Therm Sales (10/1/01 - 9/30/02)
Blocks 1 and 2 Therm Sales
Percent Therm Sales between Blocks 1 and 2
Proposed Adjustment to T-1 Tariff (1)
Industrial Therm Sales (10/1/01 - 9/30/02)
Annualized Adjustment (Line 4 multiplied by Line 5)
Annualized Adjustment (Line 4 multiplied by Line 5)
Percent Annualized Sales included in Block 1
Adjustment to Block 1 (Line 7 mulitplied by Line 8)
Block 1 Therms
Price AdjustmentlTherm Block 1 (Line 9 divided by Line 10)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmentlTherm Block 1
Annualized Adjustment (Line 4 multiplied by Line 5)
Percent Annualized Sales included in Block 2
Adjustment to Block 2 (Line 14 multiplied by Line 15)
Block 2 Therms
Price AdjustmentlTherm Block 2 (Line 16 divided by Line 17)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmentlTherm Block 2
Total Price AdjustmentlTherm Block 3
Block 1 Block 2
Therm Sales Therm Sales
(b)(c)
998,543 820 513
998,543 820,513
78.167%21.833%
Workpaper No.
Case No. INT-O3-
Intermountain Gas Company
Page 1 of
Block 3
Therm Sales
(d)
2,436 615
(1) See Exhibit No.4. Line 37. Col. (I) minus the difference of Line 22, Col. (0 minus Line 22, Col. (c)
(2) See Exhibit No.4, Line 22, Col. (0 minus Line 22, Col. (c)
Total
(e)
38,255 671
35,819 056
100.000%
(0.00421 )
255 671
(161,056)
(161 056)
78.167%
(125,893)
998 543
(0.00450)
00000
(0.00450)
(161 056)
21.833%
(35,163)
820,513
(0.00450)
00000
(0.00450)